Gas separator

ABSTRACT

A reservoir fluid conducting system for use within a wellbore is disclosed. The system includes a flow diverter fluidly coupled to downhole disposed conductor and a pump fluidly coupled to the flow diverter. The flow diverter includes a flow diverter body that defines a reservoir fluid receiving space and a gas-depleted reservoir fluid receiving space separated and fluidly isolated from the reservoir fluid receiving space. In use, reservoir fluid is received within the reservoir fluid receiving space and conducted uphole to a reservoir fluid separation space via the flow diverter where, within the reservoir fluid separation space, a gas-depleted reservoir fluid is obtained and collects within the gas-depleted reservoir fluid receiving space. The pump is disposed in fluid communication with the gas-depleted reservoir fluid separation space such that the gas-depleted reservoir fluid is pressurized by the pump and conducted to the surface via a gas-depleted reservoir fluid-producing conductor.

CROSS REFERENCE TO RELATED APPLICATIONS

This application claims priority under 35 U.S.C. § 120 from U.S. Provisional Patent Application No. 62/798,791 filed on Jan. 30, 2019, and the entire content is incorporated herein by reference.

FIELD

The present disclosure relates to mitigating downhole pump gas interference and the stresses applied to downhole wellbore equipment during coupling and de-coupling operations, as well as the adverse effects of solid particulate matter entrainment, during hydrocarbon production.

BACKGROUND

Downhole pump gas interference is a problem encountered while producing wells, especially wells with horizontal sections. In producing reservoir fluids containing a significant fraction of gaseous material, the presence of such gaseous material hinders production by contributing to sluggish flow. Additionally, solid particulate material is entrained in reservoir fluids, and such solid particulate matter can adversely affect production operations.

The installation or incorporation of gas separators into wellbore string components or equipment that include pump assemblies often requires fixed connections between sections of tubing or various fluid conductors. The connection and disconnection of these various tubing sections or fluid conductors with other wellbore tools or equipment, for example pump assemblies, for various wellbore operations and/or wellbore maintenance applies can, in some instance, apply stresses to the tubing and/or downhole wellbore equipment. Accordingly, wellbore equipment that minimizes the number of fixed connections between tubing strings and/or fluid conductors, etc. is desirable.

SUMMARY

In one aspect, there is provided a reservoir fluid conducting system disposed within a wellbore that extends into a subterranean formation and is lined with a wellbore string, wherein the system comprises:

-   -   a downhole-disposed conductor for receiving the reservoir fluid         from a downhole wellbore space;     -   a flow diverter fluidly coupled to the downhole disposed         conductor, the flow diverter including a flow diverter body         extending between an open lower end and an open upper end and         defining an open interior space therebetween;     -   a pump fluidly coupled to the flow diverter body; and     -   a gas-depleted reservoir fluid-producing conductor fluidly         coupled to the pump for conducting gas-depleted reservoir fluid,         that has been pressurized by the pump, to the surface;     -   wherein:     -   the downhole-disposed conductor, the pump, the flow diverter         body, and the gas-depleted reservoir fluid-producing conductor         are co-operatively configured such that the flow diverter body         defines:         -   a reservoir fluid receiving space disposed within the open             interior space of the flow diverter body for receiving             reservoir fluid discharged from the downhole disposed             conductor;         -   a gas-depleted reservoir fluid receiving space disposed             within the open interior space of the flow diverter body             uphole of the reservoir fluid receiving space; and         -   a sealed interface fluidly isolating the gas-depleted             reservoir fluid receiving space from the reservoir fluid             receiving space;     -   and     -   while the downhole-disposed conductor is receiving reservoir         fluid from the downhole wellbore space that has been received         within the downhole wellbore space from the subterranean         formation:         -   the reservoir fluid is conducted uphole to a reservoir fluid             separation space via the flow diverter where, within the             reservoir fluid separation space, a gas-depleted reservoir             fluid is separated from the reservoir fluid, in response to             at least buoyancy forces, such that the gas-depleted             reservoir fluid is obtained;         -   the gas-depleted reservoir fluid obtained within the             reservoir fluid separation space is received by the flow             diverter body and conducted to the pump via the gas-depleted             reservoir fluid receiving space; and         -   the gas-depleted reservoir fluid is pressurized by the pump             and conducted to the surface via the gas-depleted reservoir             fluid-producing conductor.

In another aspect, there is provided a reservoir fluid conducting system disposed within a wellbore that extends into a subterranean formation and is lined with a wellbore string that includes a wellbore string-defined flow diverter counterpart, wherein the system comprises:

-   -   a downhole-disposed conductor for receiving the reservoir fluid         from a downhole wellbore space; and     -   a production assembly, suspended within the wellbore, including:         -   an assembly-defined flow diverter counterpart;         -   a pump; and         -   a gas-depleted reservoir fluid-producing conductor for             conducting gas-depleted reservoir fluid, that has been             pressurized by the pump, to the surface;     -   wherein:     -   the assembly-defined flow diverter counterpart includes a flow         diverter body, the flow diverter body extending between an open         lower end and an open upper end and defining an open interior         space therebetween; and     -   the wellbore string-defined flow diverter counterpart and the         assembly-defined flow diverter counterpart are co-operatively         configured to define a flow diverter;     -   wherein:         -   the pump is releasably connected to the flow diverter; and         -   the flow diverter body defines a reservoir fluid receiving             space disposed within the open interior space of the flow             diverter body for receiving reservoir fluid discharged from             the downhole disposed conductor, and a gas-depleted             reservoir fluid receiving space disposed within the open             interior space of the flow diverter body uphole of the             reservoir fluid receiving space, the reservoir fluid             receiving space and the gas-depleted reservoir fluid             receiving space being cooperatively configured such that the             reservoir fluid receiving space is fluidly isolated from the             gas-depleted reservoir fluid receiving space; and         -   the downhole-disposed conductor, the flow diverter body, the             pump, and the gas-depleted reservoir fluid-producing             conductor are co-operatively configured such that, while the             downhole-disposed conductor is receiving reservoir fluid             from the downhole wellbore space that has been received             within the downhole wellbore space from the subterranean             formation:         -   the reservoir fluid is received within the reservoir fluid             receiving space and conducted uphole to a reservoir fluid             separation space via the flow diverter;         -   within the reservoir fluid separation space, a gas-depleted             reservoir fluid is separated from the reservoir fluid, in             response to at least buoyancy forces, such that the             gas-depleted reservoir fluid is obtained;         -   the gas-depleted reservoir fluid obtained within the             reservoir fluid separation space is received within the flow             diverter body and conducted to the pump via the gas-depleted             reservoir fluid receiving space; and         -   the gas-depleted reservoir fluid is pressurized by the pump             and conducted to the surface via the gas-depleted reservoir             fluid-producing conductor.

In another aspect, there is provided a reservoir fluid production assembly for disposition within a wellbore that extends into a subterranean formation and is lined with a wellbore string, wherein the reservoir fluid production assembly comprises:

-   -   an assembly-defined flow diverter counterpart;     -   a pump; and     -   a gas-depleted reservoir fluid-producing conductor fluidly         coupled to the pump for conducting gas-depleted reservoir fluid,         that has been pressurized by the pump, to the surface;     -   wherein the assembly-defined flow diverter counterpart includes:         -   a pump-seating body for receiving and releasably-connecting             with the pump; and         -   a flow diverter body extending between an open upper end and             an open lower end, the flow diverter body defining:             -   a gas-depleted reservoir fluid receiver disposed at the                 open upper end of the flow diverter body for receiving                 gas-depleted reservoir fluid obtained within a reservoir                 fluid separation space;             -   a gas-depleted reservoir fluid receiving space for                 receiving gas-depleted reservoir fluid from the                 gas-depleted reservoir fluid receiver;             -   a reservoir fluid receiving space disposed downhole from                 the gas-depleted reservoir fluid receiving space for                 receiving reservoir fluid from the subterranean                 formation, the reservoir fluid receiving space being                 fluidly isolated from the gas-depleted reservoir fluid                 receiving space; and             -   a reservoir fluid discharge opening disposed at the open                 lower end of the flow diverter body;     -   and         -   a first supporting member for suspending the flow diverter             body from the pump seating body;     -   wherein the pump-seating body, the flow diverter body, the pump,         the gas-depleted reservoir fluid-producing conductor and the         supporting member are co-operatively configured such that:         -   the pump-seating body is disposed within the open upper end             of the flow diverter body such that the pump-intake             conducting passage is fluidly coupled to the gas-depleted             reservoir fluid receiving space for conducting gas-depleted             reservoir fluid to the pump for displacement uphole via the             gas-depleted reservoir fluid-producing conductor; and         -   the flow diverter body is suspended from the pump-seating             body by the supporting member such that a gas-depleted             reservoir fluid conducting passage is disposed between the             pump-intake conducting passage and the flow diverter body             for conducting gas-depleted reservoir fluid received within             the gas-depleted reservoir fluid receiver to the             gas-depleted reservoir fluid receiving space.

BRIEF DESCRIPTION OF THE DRAWINGS

Reference will now be made, by way of example, to the accompanying drawings which show example embodiments of the present application, and in which:

FIG. 1 is a schematic illustration of an example embodiment of a system including a reservoir fluid production assembly disposed within a wellbore according to the present disclosure; and

FIG. 2 is a schematic illustration of another example embodiment of a system including a reservoir fluid production assembly disposed within a wellbore according to the present disclosure.

Similar reference numerals may have been used in different figures to denote similar components.

DESCRIPTION OF EXAMPLE EMBODIMENTS

As used herein, the terms “up”, “upward”, “upper”, or “uphole”, mean, relativistically, in closer proximity to the surface 106 and further away from the bottom of the wellbore, when measured along the longitudinal axis of the wellbore 102. The terms “down”, “downward”, “lower”, or “downhole” mean, relativistically, further away from the surface 106 and in closer proximity to the bottom of the wellbore 102, when measured along the longitudinal axis of the wellbore 102.

Referring to FIGS. 1 and 2, there are provided systems 8, with associated apparatuses, for producing hydrocarbons from a reservoir, such as an oil reservoir, within a subterranean formation 100, when reservoir pressure within the oil reservoir is insufficient to conduct hydrocarbons to the surface 106 through a wellbore 102.

The wellbore 102 can be straight, curved, or branched. The wellbore 102 can have various wellbore sections. A wellbore section is an axial length of a wellbore 102. A wellbore section can be characterized as “vertical” or “horizontal” even though the actual axial orientation can vary from true vertical or true horizontal, and even though the axial path can tend to “corkscrew” or otherwise vary. In some embodiments, for example, the central longitudinal axis of the passage 102CC defined by a horizontal section 102C is disposed along an axis that is between about 70 and about 110 degrees relative to the vertical “V”, the central longitudinal axis of the passage 102AA of a vertical section 102A is disposed along an axis that is less than about 20 degrees from the vertical “V”, and a transition section 102B is disposed between the sections 102A and 102C. In some embodiments, for example, the transition section 102B joins the sections 102A and 102C. In some embodiments, for example, the vertical section 102A extends from the transition section 102B to the surface 106.

“Reservoir fluid” is fluid that is contained within an oil reservoir. Reservoir fluid may be liquid material, gaseous material, or a mixture of liquid material and gaseous material. In some embodiments, for example, the reservoir fluid includes water and hydrocarbons, such as oil, natural gas condensates, or any combination thereof.

Fluids may be injected into the oil reservoir through the wellbore to effect stimulation of the reservoir fluid. For example, such fluid injection is effected during hydraulic fracturing, water flooding, water disposal, gas floods, gas disposal (including carbon dioxide sequestration), steam-assisted gravity drainage (“SAGD”) or cyclic steam stimulation (“CSS”).

In some embodiments, for example, the same wellbore is utilized for both stimulation and production operations, such as for hydraulically fractured formations or for formations subjected to CSS. In some embodiments, for example, different wellbores are used, such as for formations subjected to SAGD, or formations subjected to waterflooding.

A wellbore string 113 is employed within the wellbore 102 for stabilizing the subterranean formation 100. In some embodiments, for example, the wellbore string 113 also contributes to effecting fluidic isolation of one zone within the subterranean formation 100 from another zone within the subterranean formation 100.

The fluid productive portion of the wellbore 102 may be completed either as a cased-hole completion or an open-hole completion.

A cased-hole completion involves running wellbore casing 113A down into the wellbore through the production zone. In this respect, in the cased-hole completion, the wellbore string 113 includes wellbore casing 113A.

The annular region between the deployed wellbore casing and the oil reservoir may be filled with cement for effecting zonal isolation (see below). The cement is disposed between the wellbore casing and the oil reservoir for the purpose of effecting isolation, or substantial isolation, of one or more zones of the oil reservoir from fluids disposed in another zone of the oil reservoir. Such fluids include reservoir fluid being produced from another zone of the oil reservoir (in some embodiments, for example, such reservoir fluid being flowed through a production tubing string disposed within and extending through the wellbore casing to the surface), or injected fluids such as water, gas (including carbon dioxide), or stimulations fluids such as fracturing fluid or acid. In this respect, in some embodiments, for example, the cement is provided for effecting sealing, or substantial sealing, of flow communication between one or more zones of the oil reservoir and one or more others zones of the oil reservoir (for example, such as a zone that is being produced). By effecting the sealing, or substantial sealing, of such flow communication, isolation, or substantial isolation, of one or more zones of the oil reservoir, from another subterranean zone (such as a producing formation), is achieved. Such isolation or substantial isolation is desirable, for example, for mitigating contamination of a water table within the oil reservoir by the reservoir fluid (e.g. oil, gas, salt water, or combinations thereof) being produced, or the above-described injected fluids.

In some embodiments, for example, the cement is disposed as a sheath within an annular region between the wellbore casing and the oil reservoir. In some embodiments, for example, the cement is bonded to both of the production casing and the subterranean formation 100.

In some embodiments, for example, the cement also provides one or more of the following functions: (a) strengthens and reinforces the structural integrity of the wellbore, (b) prevents, or substantially prevents, produced reservoir fluid of one zone from being diluted by water from other zones. (c) mitigates corrosion of the wellbore casing, (d) at least contributes to the support of the wellbore casing, and e) allows for segmentation for stimulation and fluid inflow control purposes.

The cement is introduced to an annular region between the wellbore casing and the subterranean formation 100 after the subject wellbore casing has been run into the wellbore 102. This operation is known as “cementing”.

In some embodiments, for example, the wellbore casing includes one or more casing strings, each of which is positioned within the well bore, having one end extending from the well head. In some embodiments, for example, each casing string is defined by jointed segments of pipe. The jointed segments of pipe typically have threaded connections.

Typically, a wellbore contains multiple intervals of concentric casing strings, successively deployed within the previously run casing. With the exception of a liner string, casing strings typically run back up to the surface 106. Typically, casing string sizes are intentionally minimized to minimize costs during well construction. Generally, smaller casing sizes make production and artificial lifting more challenging.

For wells that are used for producing reservoir fluid, few of these actually produce through wellbore casing. This is because producing fluids can corrode steel or form undesirable deposits (for example, scales, asphaltenes or paraffin waxes) and the larger diameter can make flow unstable. In this respect, a production string is usually installed inside the last casing string. The production string is provided to conduct reservoir fluid, received within the wellbore, to the 116. In some embodiments, for example, the annular region between the last casing string and the production tubing string may be sealed at the bottom by a packer 500.

The wellbore 102 is disposed in flow communication (such as through perforations provided within the installed casing or liner, or by virtue of the open hole configuration of the completion), or is selectively disposable into flow communication (such as by perforating the installed casing, or by actuating a valve to effect opening of a port), with the subterranean formation 100. When disposed in flow communication with the subterranean formation 100, the wellbore 102 is disposed for receiving reservoir fluid flow from the subterranean formation 100, with effect that the system 8 receives the reservoir fluid.

In some embodiments, for example, the wellbore casing is set short of total depth. Hanging off from the bottom of the wellbore casing, with a liner hanger or packer, is a liner string. The liner string can be made from the same material as the casing string, but, unlike the casing string, the liner string does not extend back to the wellhead 116. Cement may be provided within the annular region between the liner string and the oil reservoir for effecting zonal isolation (see below), but is not in all cases. In some embodiments, for example, this liner is perforated to effect flow communication between the reservoir and the wellbore. In this respect, in some embodiments, for example, the liner string can also be a screen or is slotted. In some embodiments, for example, the production tubing string may be engaged or stung into the liner string, thereby providing a fluid passage for conducting the produced reservoir fluid to the wellhead 116. In some embodiments, for example, no cemented liner is installed, and this is called an open hole completion or un-cemented casing completion.

An open-hole completion is effected by drilling down to the top of the producing formation, and then lining the wellbore (such as, for example, with a wellbore string 113). The wellbore is then drilled through the producing formation, and the bottom of the wellbore is left open (i.e. uncased), to effect flow communication between the reservoir and the wellbore. Open-hole completion techniques include bare foot completions, pre-drilled and pre-slotted liners, and open-hole sand control techniques such as stand-alone screens, open hole gravel packs and open hole expandable screens. Packers and casing can segment the open hole into separate intervals and ported subs can be used to effect flow communication between the reservoir and the wellbore.

Referring now to FIGS. 1 and 2 there are shown example embodiments of reservoir fluid production systems according to example embodiments of the present disclosure.

In some embodiments, for example, the system 8, includes a downhole disposed conductor 202 for receiving reservoir fluid from a downhole wellbore space 110. A flow diverter 600 is fluidly coupled to the downhole disposed conductor 202 and a pump 302 is fluidly coupled to flow diverter 600. In some embodiments, for example, the pump is releasably coupled to the flow diverter 600. A gas-depleted reservoir fluid producing conductor 204 is fluidly coupled to the pump 302 for conducting gas-depleted reservoir fluid, that has been pressurized by the pump 302, to the surface 106. The downhole-disposed conductor 202, the flow diverter 600, the pump 302, and the gas-depleted reservoir fluid-producing conductor 204 are co-operatively configured such that, while the downhole-disposed conductor 202 is receiving reservoir fluid from the downhole wellbore space 110, which reservoir fluid has been received within the downhole wellbore space 110 from the subterranean formation 100, the reservoir fluid is conducted uphole to a reservoir fluid separation space 112X via the flow diverter 600 where, within the reservoir fluid separation space 112X, a gas-depleted reservoir fluid is separated from the reservoir fluid, in response to at least buoyancy forces, such that the gas-depleted reservoir fluid is obtained.

The flow diverter 600 is provided for, amongst other things, mitigating gas lock within the pump 302. In this respect, the flow diverter 600 is configured for receiving reservoir fluid that has been received by the wellbore 102 within the downhole wellbore space 110 from the subterranean formation 100, and separating gaseous material from the received reservoir fluid, in response to at least buoyancy forces, such that the gas-depleted reservoir fluid is obtained. In some embodiments, for example, the flow diverter 600 is disposed within a vertical portion 102A of the wellbore 102 that extends to the surface 106. The flow diverter 600 is fluidly coupled to the pump 302 for effecting supply of the gas-depleted reservoir fluid received within the flow diverter 600 to the pump 302.

The pump 302 is provided to, through mechanical action, pressurize and effect conduction of the gas-depleted reservoir fluid to the surface 106, and thereby effect production of the gas-depleted reservoir fluid via the gas-depleted reservoir fluid producing conductor 204. In some embodiments, for example, the pump 302 is a sucker rod pump. Other suitable pumps 302 include screw pumps, electrical submersible pumps, jet pumps, and plunger lift, for example.

In some embodiments, for example, the system 8 includes a production assembly 10. The production assembly 10 is suspended within the wellbore 102 from the wellhead 116.

In some embodiments, for example, the assembly 10 includes the pump 302 and the gas-depleted reservoir fluid-producing conductor 204, and the flow diverter 600. The gas-depleted reservoir fluid-producing conductor 204 is fluidly coupled to the pump 302 for conducting the pressurized gas-depleted reservoir fluid that is received by the pump 302, to the surface 106.

The assembly 10 is disposed within the wellbore string 113, such that an intermediate wellbore passage 112 is defined within the wellbore string 113, between the assembly 10 and the wellbore string 113. In some embodiments, for example, the intermediate wellbore passage 112 is an annular space disposed between the assembly 10 and the wellbore string 113. In some embodiments, for example, the intermediate wellbore passage 112 is defined by the space that extends outwardly, relative to the central longitudinal axis of the assembly 10, from the assembly 10 to the wellbore fluid conductor 113. In some embodiments, for example, the intermediate wellbore passage 112 extends longitudinally to the wellhead 116, between the assembly 10 and the wellbore string 113.

In some embodiments, the flow diverter 600 includes a wellbore string counterpart 600B and an assembly counterpart 600C. The wellbore string 113 defines the wellbore string counterpart 600B, and the assembly 10 defines the assembly counterpart 600C. The flow diverter defines: (i) a reservoir fluid-conducting passage 6002 for conducting reservoir fluid that is received within a downhole wellbore space from the subterranean formation 100, to the reservoir fluid separation space 112X of the wellbore 102, with effect that gas-depleted reservoir fluid is separated from the reservoir fluid within the reservoir fluid separation space 112X in response to at least buoyancy forces; and (ii) a gas-depleted reservoir fluid conducting passage 6004 for receiving the separated gas-depleted reservoir fluid while the separated gas-depleted reservoir fluid is flowing in a downhole direction, and diverting the flow of the received gas-depleted reservoir fluid such that the received gas-depleted reservoir fluid is conducted by the flow diverter 600 in the uphole direction to the pump 302.

In some embodiments, for example, the assembly counterpart 600C includes a flow diverter body 602 and, in some embodiments, the flow diverter body 602 includes a shroud 603. In this respect, the shroud 603 is cooperatively disposed relative to the wellbore string counterpart 600B such that an intermediate reservoir fluid-conducting passage 1112 (such as, for example, an annular fluid passage) is disposed between the shroud 603 and the wellbore string counterpart 600B. The intermediate reservoir fluid conducting passage 1112 forms part of the reservoir fluid conducting passage 6002. In some embodiments, for example, the intermediate reservoir fluid-conducting passage 1112 includes the reservoir fluid-conducting passage 6002 and is disposed for conducting the received reservoir fluid to the reservoir fluid separation space 112X. In some embodiments, for example, the intermediate wellbore passage 112 includes the intermediate reservoir fluid-conducting passage 1112 and the reservoir fluid-conducting passage 6002.

In some embodiments, for example, the flow diverter body 602 or shroud 603 includes a tubular member that extends between an open upper end 604 and an open lower end 606 and defines an open interior space therebetween.

In some embodiments, for example, the wellbore string 113 or the wellbore string counterpart 600B is defined by a 5½″ casing.

In some embodiments, the flow diverter body 602 or shroud 603 includes an opening 605 for receiving the separated gas-depleted reservoir fluid such that the separated gas-depleted reservoir fluid is conducted via the gas-depleted reservoir fluid conducting passage 6004 to the pump 302. In this respect, the opening 605 defines a gas-depleted reservoir fluid receiver. In some embodiments, for example, the opening 605 is disposed at an uphole end of the shroud 603 or flow diverter body 602, and the gas-depleted reservoir fluid-conducting passage 6004 extends downhole from the uphole end for conducting the received gas-depleted reservoir fluid in a downhole direction. In some embodiments, for example, the opening 605 includes the open upper end 604 of the flow diverter body 602 or shroud 603, the flow diverter body 602 or shroud 603 being disposed within the wellbore 102 such that the opening upper end 604 is disposed for receiving the separated gas-depleted reservoir fluid, the open upper end 604 therefore serving as the gas-depleted reservoir fluid receiver. The reservoir fluid separation space 112X is disposed uphole, such as vertically above, the opening 605 or open upper end 604 of the flow diverter body 602 or shroud 603.

In some embodiments, the flow diverter body 602, or shroud 603, is disposed within the wellbore 113 such that it cooperates with a wellbore string counterpart 602B defined by a corresponding portion of the wellbore string 113. The flow diverter body 602 is disposed within the wellbore 113 and is cooperatively configured with the wellbore string counterpart 602B to define the intermediate reservoir fluid-conducting passage 6002 for conducting reservoir fluid that is received within a downhole wellbore space 110 from the subterranean formation 100 and conducted to an uphole wellbore space 108 via the downhole disposed conductor 202, to the reservoir fluid separation space 112X of the wellbore 102 where, within the reservoir fluid separation space 112X, the gas-depleted reservoir fluid is separated from the reservoir fluid in response to at least buoyancy forces. In some embodiments, for example, the reservoir fluid separation space 112X is configured such that, in operation, while reservoir fluid is being supplied to the reservoir fluid separation space 112X, the velocity of the gaseous portion of the reservoir fluid being conducted via the intermediate reservoir fluid conducting passage 6002 is greater than the critical liquid lifting velocity, and while the reservoir fluid is disposed within the reservoir fluid separation space 112X, the velocity of the gaseous portion of the reservoir fluid is sufficiently low such that the above-described separation is effected.

In some embodiments, there is provided a pump assembly and the pump assembly includes the pump 302 and a pump-seating body 700. The pump-seating body defines a pump-seating receptacle for receiving and releasably connecting with the pump 302. The pump-seating body 700 also defines a pump-intake conducting passage 704 for conducting the gas-depleted reservoir fluid obtained within the reservoir fluid separation space 112X to the pump 302. In some embodiments, the pump-seating receptacle 702 includes a pump-seating nipple 705 for effecting the releasable coupling or releasable connection between the pump 302 and the pump-seating body 700 such that the pump 302 is disposed for receiving the gas-depleted reservoir fluid.

In some embodiments, the flow diverter body 602 or shroud 603 and the pump-seating body 700 are cooperatively configured such that the gas-depleted reservoir fluid conducting passage 6004 is disposed between the shroud 603 and the pump-seating body 700 for delivering the gas-depleted reservoir fluid obtained within the reservoir fluid separation space 112X to the pump 302 via the pump-intake conducting passage 704.

In some embodiments, for example, the flow diverter body 602 or shroud 603 and the pump-seating body 700 are cooperatively configured such that bypassing of the pump-intake conducting passage 704 by the gas-depleted reservoir fluid that is received and conducted by the gas-depleted reservoir fluid conducting passage 6004 is prevented or substantially prevented. In this respect, in some embodiments, for example, the flow diverter body 602 includes a flow-blocking member or sealed interface 800 disposed intermediate the open upper end 604 and the open lower end 606 for preventing or substantially preventing such bypassing. In some embodiments, the sealed interface 800 is disposed within the flow diverter body 602 or shroud 603 such that the sealed interface 800 divides the opening interior space into an upper open interior space 608 and a lower open interior space 610, the upper open interior 608 being fluidly isolated from the lower open interior space 610.

In some embodiments, the pump-seating receptacle 702 has a diameter that is greater than a diameter of the pump-intake conducting passage 704.

In some embodiments, the pump-seating body 700 and the flow diverter body 602 are cooperatively configured such that the pump-seating receptacle 702 is disposed uphole of the open upper end 604 of the flow diverter body 602 with the pump-intake conducting passage 704 extending into the upper open interior space 608 of the flow diverter body 602 through the open upper end 604 such that the gas-depleted reservoir fluid-conducting passage 6004 is defined between the pump-intake conducting passage 704 of the pump-seating body 700 and the flow diverter body 602 or shroud 603 for conducting the separated gas-depleted reservoir fluid that is obtained within the reservoir fluid separation space 112X to a gas-depleted reservoir fluid receiving space 6006 defined within the flow diverter body 602 uphole of the sealed interface 800 from where it is conducted to the pump 302 via the pump-intake conducting passage 704 where the fluid is pressurized by the pump 302 and conducted uphole to the surface 106 via the gas-depleted reservoir fluid producing conductor 204. In this respect, the pump-seating body 700 is cooperatively configured with the flow diverter body 602 such that the pump-intake conducting passage 704 is fluidly coupled or disposed in fluid communication with the gas-depleted reservoir fluid receiving space 6006.

In some embodiments, for example, a supporting member 900 suspends the flow diverter body 602 from the pump-seating body 700 such that the gas-depleted reservoir fluid conducting passage 6004 is disposed between the pump seating body 700 and an inner surface 601 of the flow diverter body 602 or shroud 603. Therefore, in some embodiments, the pump-seating body 700, the supporting member 900 and the flow diverter body 602 are cooperatively configured such that the gas-depleted reservoir fluid-conducting passage 6004 is defined between the pump-seating body 700 and a corresponding inner surface 601 of the flow diverter body 602. In some embodiments, for example, the gas-depleted reservoir fluid-conducting passage 6004 is an annular space disposed between the pump-seating body 700 and the flow diverter body 602. In some embodiments, the gas-depleted reservoir fluid-conducting passage 6004 is defined by the space that extends outwardly, relative to the central longitudinal axis of the assembly 10, from the pump-seating body 700 to the flow diverter body 602. In some embodiments, the gas-depleted reservoir fluid-conducting passage 6004 extends longitudinally from the open upper end 606 of the flow diverter body 602 to the closed end defined within the flow diverter body 602 by the sealed interface 800 in the space between the pump seating body 700 and the flow diverter body 602.

In some embodiments, for example, the sealed interface 800 is disposed within the flow diverter body 602 and divides the flow diverter body 602, or shroud 603, into the upper interior space 608 that extends between one side of the sealed interface 800 and the open upper end 604 of the flow diverter body 602, and a lower interior space 610 that extends between the opposite side of the sealed interface 800 and the open lower end 606 of the flow diverter body 602. Accordingly, in some embodiments the closed end of the gas-depleted reservoir fluid-conducting passage 6004 is defined by one side of the sealed interface 800.

In some embodiments, the gas-depleted reservoir fluid receiving space 6006 is disposed within the upper interior space 608 of the flow diverter body 602. In some embodiments, therefore, the gas-depleted reservoir fluid receiving space 6006 is defined at a bottom end of the upper interior space 608 of the flow diverter body 602. In some embodiments, disposition of the flow blocking member or sealed interface 800 within the flow diverter body 602, or shroud 603, is such that a sealed interface is effected between the inner surface 601 of the flow diverter body 602 and the corresponding surface of flow-blocking member or sealed interface 800 such that the upper interior space 608 is fluidly isolated from the lower open interior space 610.

In some embodiments, the supporting member 900 includes a hanger assembly. In some embodiments, the supporting member 900 is disposed uphole of the flow diverter flow blocking member 800 and is selected such that the supporting member 900, or hanger assembly, does not impede fluid flow within the gas-depleted reservoir fluid conducting passage 6004. Therefore, in some embodiments, the supporting member 900, or hanger assembly, is selected such that suspension of the flow diverter body 602 from the pump-seating body 700 is with effect that fluid flow of the gas-depleted reservoir fluid from the wellbore separation space 112X to the gas-depleted reservoir fluid receiving space 6006 across the supporting member 900, or hanger assembly, is permitted. In some embodiments, the supporting member 900, or hanger assembly, is selected such that suspension of the flow diverter body 602 from the pump-seating body 700 is with effect that interference to the flow of gas-depleted reservoir fluid within the gas-depleted reservoir fluid conducting passage 6004 to the gas-depleted reservoir fluid receiving space 6006 is prevented, or substantially prevented.

In some embodiments, a further supporting member 902 supports the assembly counterpart 600C within the wellbore string 113 or relative to the wellbore counterpart 600B. In some embodiments, for example, the supporting member 902 supports the flow diverter body 602 or shroud 603 within the wellbore 102 relative to a corresponding portion of the wellbore string 113. In this respect, the supporting member 902 supports the flow diverter body 602 or shroud 603 relative to the corresponding portion of the wellbore string 113 such that it does not impede, or substantially does not impede, flow through the intermediate reservoir fluid conducting passage 6002. In some embodiments, for example, the supporting member 902 includes a hanger assembly.

In some embodiments, for example as shown in FIG. 2, the sealed interface 800 includes the supporting member 900, as will be described in further detail below in reference to the example embodiment illustrated in FIG. 2. In such embodiments, the sealed interface 800 prevents, or substantially prevents, fluid flow across the sealed interface 800 while supporting the flow diverter body 602 from the pump-seating body 700.

Referring again to FIG. 1, in some embodiments, the pump-seating body 700 is disposed within the flow diverter body 602, or shroud 603, such that the pump-seating body 700 has a distal end 706 that is disposed within the open upper interior space 608 and is spaced apart from the flow diverter flow-blocking member or sealed interface 800. In some embodiments, the gas-depleted reservoir fluid receiving space 6006 is defined within the upper interior space 608 of the flow diverter body 602 between the sealed interface 800 and the distal end 706 of the pump-seating body 700.

In some embodiments, the pump-intake conducting passage 704 extends between the distal end 706 of the pump-seating body 700 and the pump-seating receptacle 702, and disposition of the pump-seating body 700 within the flow diverter 602 is such that the pump-intake conducting passage 704 is disposed in fluid communication with the gas-depleted reservoir fluid receiving space 6006. Therefore, while gas-depleted reservoir fluid is being received within the gas-depleted reservoir fluid receiving space 6006 from the wellbore separation space 112X via the gas-depleted reservoir fluid conducting passage 6004, gas-depleted reservoir fluid is supplied to the pump 302 via the pump-intake conducting passage 704.

The flow diverter body 602, or shroud 603, further defines a reservoir fluid receiving space 6008 for receiving reservoir fluid that is conducted from the downhole wellbore space 110 to the uphole wellbore space 108. In some embodiments, the downhole disposed conductor 202 and the flow diverter 600 are cooperatively configured such that the downhole disposed conductor 202 is disposed in fluid communication with the reservoir fluid receiving space 6008 such that the reservoir fluid that is received within the downhole wellbore space 110 from the subterranean 100 and is conducted uphole to the uphole wellbore space 108 via the downhole disposed conductor 202 is discharged into the reservoir fluid receiving space 6008 from where it is conducted to the wellbore separation space 112X.

In some embodiments, for example, the downhole disposed conductor 202 includes a discharge end 203 from which reservoir fluid, that is received within the downhole wellbore space 110 from the subterranean formation 100, is discharged uphole into the reservoir fluid receiving space 6008 defined by the flow diverter body 602, or shroud 603.

In some embodiments, the flow diverter body 602 and the downhole disposed conductor 202 are cooperatively configured such that a reservoir fluid conducting passage 6010 fluidly interconnects the reservoir fluid receiving space 6008 and the intermediate reservoir fluid conducting passage 6002, the reservoir fluid receiving space 6008 being defined within the lower interior space 610 of the flow diverter body 602 downhole of the sealed interface 800. In this respect, the reservoir fluid conducting passage 6010 extends between the closed, upper end of the lower interior space 610, as defined by the sealed interface 800 to the open, lower end 606 of the flow diverter body 602 or shroud 603, the open lower end 606 therefore, in some embodiments, serving as a received reservoir fluid outlet 611.

As shown in FIG. 1, in some embodiments, the downhole disposed conductor 202 and the flow diverter body 602 are cooperatively configured such that the downhole disposed conductor 202 is disposed within the open lower end 606 of the flow diverter body 602, or shroud 603, such that the discharge end 203 of the downhole disposed conductor 202 is spaced apart from the sealed interface 800. Therefore, in some embodiments, the flow diverter body 602, the sealed interface 800 and the downhole disposed conductor 202 are cooperatively configured such that the discharge end 203 of the downhole disposed conductor 202 remains spaced apart from the flow diverter flow-blocking member or sealed interface 800 and free from any connection to or free from support from the flow diverter body 602 or shroud 603. Therefore, in some embodiments, for example, there is an absence, or a substantial absence, of support to the downhole disposed conductor 202 by the assembly 10. Therefore, in the subject example embodiment, for example, the downhole disposed conductor 202 is not subject to the same degree of stress that can be effected where there are fixed connections between the various fluid conducting members within the overall system 8. Therefore, the absence of a fixed connection between the production assembly 10 and the downhole disposed conductor 202 serves to relieve stress that would otherwise be experienced by the downhole disposed conductor 202 caused by movement of either the pump-assembly or downhole disposed conductor 202 during maintenance and/or other downhole operations thereby leaving the downhole disposed conductor free from, or substantially free from, stresses typically associated with pump-connection/disconnection operations.

In some embodiments, the reservoir fluid receiving space 6008 is defined within the lower open space 610 of the flow diverter body 602 between the discharge end 203 of the downhole disposed conductor 202 and the sealed interface 800 while the reservoir fluid-conducting passage 6010 is defined between the downhole disposed conductor 202 and a corresponding inner surface of the flow diverter body 602. In some embodiments, for example, the reservoir fluid-conducting passage 6010 is an annular space disposed between the downhole disposed conductor 202 and the flow diverter body 602. In some embodiments, the reservoir fluid-conducting passage 6010 is defined by the space that extends outwardly, relative to the central longitudinal axis of the assembly 10, from at least a vertical, or substantially vertical, portion of the downhole disposed conductor 202 to the flow diverter body 602. In some embodiments, the reservoir fluid-conducting passage 6010 extends longitudinally from the sealed interface 800 to the open lower end 606 of the flow diverter body 602 between the downhole disposed conductor 202 and the flow diverter body 602.

In some embodiments, for example, the system 8 also includes a wellbore string sealed interface 500 for preventing, or substantially preventing, bypassing of the reservoir fluid separation space 112X by the reservoir fluid that is supplied to the uphole wellbore space 108 by the downhole-disposed conductor 202. In some embodiments, for example, the sealed interface 500 is defined by a sealed interface effector 502, such as, for example, a packer.

In some embodiments, for example, the sealed interface 500 is defined within the wellbore 102, between: (a) the uphole wellbore space 108 of the wellbore 102, and (b) the downhole wellbore space 110 of the wellbore 102. In some embodiments, for example, the disposition of the sealed interface 500 is such that flow communication, via the intermediate wellbore passage 112, between the uphole wellbore space 108 and the downhole wellbore space 110 (and across the sealed interface 500), is prevented, or substantially prevented. In some embodiments, for example, the disposition of the sealed interface 500 is such that fluid flow, across the sealed interface 500, in a downhole direction, from the uphole wellbore space 108 to the downhole wellbore space 110, is prevented, or substantially prevented. In this respect, the sealed interface 500 functions to prevent, or substantially prevent, reservoir fluid flow, that is received within the uphole wellbore space 108 via the downhole disposed conductor 202, from bypassing the reservoir fluid separation space 112X, and, as a corollary, the reservoir fluid is directed to the reservoir fluid separation space 112X, via the intermediate reservoir fluid conductor 112, for facilitating separation of gaseous material from the reservoir fluid in response to at least buoyancy forces.

In some embodiments, for example, the downhole disposed conductor 202, the flow diverter body 602, the flow diverter body sealed interface 800, the pump-seating body 700, the pump 302 and the gas-depleted reservoir fluid producing conductor 204 are cooperatively configured such that, in operation, while the downhole disposed conductor 202 is receiving reservoir fluid from the downhole wellbore space 110 that has been received within the downhole wellbore space 110 from the subterranean formation 100, the reservoir fluid is supplied to the uphole wellbore space 108 by the downhole disposed conductor 202 such that reservoir fluid is discharged from the discharge end 203 of the downhole disposed conductor 202 into the reservoir fluid receiving space 6008. The reservoir fluid received within the reservoir fluid receiving space 6008 is then conducted downhole via the reservoir fluid conducting passage 6010 and delivered to the intermediate reservoir fluid conducting passage 6002 via the received reservoir fluid outlet 611, where it is directed uphole to the reservoir fluid separation space 112X. Bypassing of the reservoir fluid separation space 112X by the reservoir fluid is prevented, or substantially prevented by the sealed interface 500 or sealed interface effector 502, such that reservoir fluid is supplied to the reservoir fluid separation space 112X by the intermediate reservoir fluid conductor 6002. Within the reservoir fluid separation space 112X, gas-depleted reservoir fluid is separated from the reservoir fluid, in response to at least buoyancy forces, such that the gas-depleted reservoir fluid is obtained. The separated gas-depleted reservoir fluid is received by a gas depleted reservoir fluid receiver 605 of the flow diverter body 602 or shroud 603 (e.g. the open upper end 604 of the flow diverter body 602 or shroud 603) and is conducted to the gas-depleted reservoir fluid receiving space 6006 via the gas-depleted reservoir fluid conducting passage 6004. From the gas-depleted reservoir fluid receiving space 6006, the separated gas-depleted reservoir fluid is conducted to the pump 302 via the pump-intake conducting passage 704. Once received by the pump 302, the gas-depleted reservoir fluid is pressurized by the pump 302 and is conducted uphole to the surface 106 as production flow via the gas-depleted reservoir fluid producing conductor 204.

In parallel, the separation of gaseous material from the reservoir fluid within the reservoir fluid separation space 112X is with effect that a liquid-depleted reservoir fluid is obtained and is conducted uphole (in the gaseous phase, or at least primarily in the gaseous phase with relatively small amounts of entrained liquid), via a liquid-depleted reservoir fluid conducting passage 6012 that is disposed between the assembly 10 and a corresponding portion of the wellbore string 113 generally uphole of the reservoir fluid separation space 112X.

The reservoir fluid produced from the subterranean formation 100, via the wellbore 102, including the gas-depleted reservoir fluid, the liquid-depleted reservoir fluid, or both, may be discharged through the wellhead 116 to a collection facility, such as a storage tank.

In some embodiments, for example, the reservoir fluid separation space 112X spans a continuous space extending from the assembly 10 to the wellbore string 113, and the continuous space extends outwardly relative to the central longitudinal axis of the assembly 10.

In some embodiments, for example, the reservoir fluid separation space 112X spans a continuous space extending from the assembly 10 to the wellbore string 113, and the continuous space extends outwardly relative to the central longitudinal axis of the wellbore 102.

In some embodiments, for example, the reservoir fluid separation space 112X is disposed within a vertical portion 102A of the wellbore 102 that extends to the surface 106.

In some embodiments, for example, the ratio of the minimum cross-sectional flow area of the reservoir fluid separation space 112X to the maximum cross-sectional flow area of the fluid passage defined by the reservoir fluid-supplying conductor 202 is at least about 1.5.

In some embodiments, for example, the uphole wellbore space 108 includes a sump space 550, and the sump space 550 is disposed: (i) downhole relative to the reservoir fluid separation space 112X (such as, for example, downhole relative to the intermediate reservoir fluid conducting passage 6002), and (ii) uphole relative to the sealed interface 500. The sump space 550 is provided for collecting solid particulate material that gravity separates from the reservoir fluid that is supplied to the uphole wellbore space 108 by the downhole-disposed conductor 202. In some embodiments, for example, the discharge end 203 of the downhole-disposed conductor 202 is disposed uphole relative to the sump space 550 and is cooperatively configured with the flow diverter body 602 such that the discharge end 203 is oriented for discharging the conducted reservoir fluid in a downhole direction towards the sump space 550. In this respect, as reservoir fluid is discharged from the discharge end 203 into the reservoir fluid receiving space 6008 defined by the flow diverter body 602, the reservoir fluid flows in the downhole direction in the reservoir fluid conducting passage towards the sump space 550, and after having flowed in the downhole direction, the reservoir fluid reverses direction and flows in an uphole direction to the reservoir fluid separation space 112X via the intermediate reservoir fluid conducting passage 6002. During the flow reversal, as the reservoir fluid is discharged from the open lower end 606 of the flow diverter body (or reservoir fluid outlet), at least a fraction of solid particulate material, that is entrained within the reservoir fluid, that is discharged into the uphole wellbore space 108 from the downhole-disposed conductor 202, becomes separated from the reservoir fluid and gravity settles within the sump space 550.

The pump-seating body 700 includes a gas-depleted reservoir fluid inlet 710 disposed uphole of the flow diverter sealed interface 800 that is disposed in fluid communication with the gas-depleted reservoir fluid receiving space 6006 such that the gas-depleted reservoir fluid is communicated to the pump-intake conducting passage 704 from the gas-depleted reservoir fluid receiving space 6006 through the gas-depleted reservoir fluid inlet 710.

In some embodiments, for example, in reference to the embodiment illustrated in FIG. 1, the gas-depleted reservoir fluid inlet 710 includes the open, distal end 706 of the pump-seating body 700. In this respect, the pump-seating body 700 is disposed within the flow diverter body 602 or shroud 603 such that the distal end 706, and therefore the gas-depleted reservoir fluid inlet 710 is disposed uphole of the flow diverter flow blocking member 800 in fluid communication or fluidly coupled to the gas-depleted reservoir fluid receiving space 6006.

Referring now in particular to FIG. 2, there is shown another example embodiment of the present disclosure, wherein the pump-seating body 700 is disposed within the flow diverter body 602 such that the pump-seating body 700 extends through the flow diverter body sealed interface 800 such that the distal end 706 of the pump-seating body 700 is disposed downhole of the sealed interface 800. In such embodiment, the flow diverter flow-blocking member 800 serves as the supporting member 900, the flow diverter body 602 therefore being suspended from the pump-seating body 700 by the flow-blocking member 800. Therefore, in some embodiments, the pump-seating body 700 and the sealed interface 800 are cooperatively configured such that a first sealed interface 802 is effected between the flow diverter body 602 or shroud 603 and the sealed interface 800, and a second sealed interface 804 is effected between the pump-seating body 700 and the flow diverter sealed interface 800, wherein the first sealed interface 802 and the second sealed interface 804, together, fluidly isolate the reservoir fluid receiving space 6008 (or lower open interior space 610 of the flow diverter body 602) from the gas-depleted reservoir fluid receiving space 6006 (or upper open interior space 608 of the flow diverter body 602).

Therefore, in the example embodiment illustrated in FIG. 2, the gas-depleted reservoir fluid inlet 710 is disposed within, or extends through, the pump-seating body 700 uphole of the open, distal end 706 of the pump-seating body 700. In some embodiments, the gas-depleted reservoir fluid inlet 710 includes an aperture or opening defined within the sidewall of the pump-intake conducting passage 704 of the pump-seating body 700 for effecting fluid communication between the gas-depleted reservoir fluid receiving space 6006 and the pump-intake conducing passage 704.

A pump-seating body flow-blocking member or sealed interface 810 is disposed within the pump-seating body 700 such that a sealed interface is effected between the pump-seating body 700 and a corresponding portion of the pump-seating body flow-blocking member or sealed interface 810, the gas-depleted reservoir fluid inlet 710 disposed within the pump-seating body 700 uphole of the pump-seating body sealed interface 810.

A reservoir fluid outlet 720 is disposed within the pump-seating body 700 downhole relative to the placement of the pump-seating body flow-blocking member 810 such that the reservoir fluid outlet 720 is in fluid communication with the reservoir fluid receiving space 6008 such that reservoir fluid that is conducted uphole from the downhole wellbore space 110, via the downhole disposed conductor 202, is communicated to the reservoir fluid receiving space 6008 through the reservoir fluid outlet 720.

In some embodiments, the pump-seating body 700 and the pump-seating body sealed interface 810 are cooperatively configured such that the gas-depleted reservoir fluid inlet 710 is disposed uphole of the pump-seating body sealed interface 810 while the reservoir fluid outlet 720 is disposed downhole of the pump-seating body sealed interface 810, the reservoir fluid outlet 720 being fluidly isolated from the gas-depleted reservoir fluid inlet 710 by the pump-seating body sealed interface 810.

As shown in FIG. 2, in some embodiments, for example, the discharge end 203 of the downhole disposed conductor 202 is configured for releasably coupling to the pump-seating body 700. In some embodiments, for example, the discharge end 203 of the downhole disposed conductor 202 is configured for releasably coupling to a reservoir fluid receiver of the production assembly 10 such that reservoir fluid that is received within the downhole wellbore space 110 and that is conducted uphole by the downhole disposed conductor 202 is discharged from the downhole disposed conductor 202 directly into a reservoir fluid receiver from where it is conducted or delivered to the reservoir fluid receiving space 6008. In some embodiments, for example, the discharge end 203 of the downhole disposed conductor 202 is configured for releasably coupling to the open distal end 706 of the pump-seating body 700, such that the downhole disposed conductor 202 is fluidly coupled to the pump-seating body 700. In some embodiments, the discharge end 203 includes an on/off tool for effecting the releasable coupling of the downhole disposed conductor 202 to the distal end 706 of the pump-seating body 700 with effect that fluid coupling of the downhole disposed conductor 202 to the reservoir fluid receiving space 6006 via the reservoir fluid outlet 720 of the pump-seating body 700 is effected. In some embodiments, the on/off tool includes lugs.

The releasable coupling of the downhole disposed conductor 202 to the pump seating body 700 is such that a reservoir fluid discharge opening 612 (or received reservoir fluid outlet 611) is defined, for example, by the annular gap or space defined between the downhole disposed conductor 202 and/or the pump-seating body 700 and the open lower end 606 of the flow diverter body 602 or shroud 603, serves to fluidly interconnect the reservoir fluid conducting passage 6010 and the intermediate reservoir fluid conducting passage 6002, the reservoir fluid conducting passage 6010 extending between the reservoir fluid receiving space 6008 and the reservoir fluid discharge opening 612.

Therefore, in some embodiments, for example, in operation, while the downhole disposed conductor 202 is releasably coupled to the reservoir fluid receiver 706 of the pump-seating body 700 and is receiving reservoir fluid received within the downhole wellbore space 110 from the subterranean formation 100, as shown in FIG. 2, the reservoir fluid is discharged into the reservoir fluid receiving space 6008, via the reservoir fluid outlet 720, disposed within the pump-seating body 700 uphole of the releasable connection between the downhole disposed conductor and the pump-seating body 700. From the reservoir fluid receiving space 6008, the reservoir fluid is conducted downhole through the reservoir fluid conducting passage 6010 before exiting the flow diverter body 602 through the reservoir fluid outlet 612. As the reservoir fluid exits or is discharged from the reservoir fluid outlet 612 or open lower end 606 of the flow diverter body 602, solid particulate may separate out of the fluid flow, in response to at least gravity, and collect on the sealed interface 500 so as not to interfere with the production of the wellbore 113. The reservoir fluid that is free from, or substantially free from, the unnecessary or unwanted particular matter travels upward or uphole to the reservoir fluid separation space 112X via the intermediate reservoir fluid conducting passage 6002. Within the reservoir fluid separation space, the gas-depleted reservoir fluid is separated from the reservoir fluid and is received within the gas-depleted reservoir fluid receiver, or open top end 606 of the flow diverter body 602. From the gas-depleted reservoir fluid receiver, the gas-depleted reservoir fluid is conducted downhole via the gas-depleted reservoir fluid conducting passage 6004 to the gas-depleted reservoir fluid receiving space 6006. From the gas-depleted reservoir fluid receiving space 6006, the gas-depleted reservoir fluid is delivered to the pump-intake conducting passage 704 through the gas-depleted reservoir fluid inlet 710 where it is conducted uphole to the pump 302 where the fluid is pressurized and conducted to the surface 106 or wellhead 116 via the gas-depleted reservoir fluid producing conductor 204.

In some embodiments, the pump-seating body 700 and the flow diverter body 602 are cooperatively configured such that the reservoir fluid receiver disposed at the distal end 706 of the pump-seating body 700 is disposed uphole of the open lower end 606 of the flow diverter body 602 such that the downhole disposed conductor 202 is releasably coupled to the pump-seating body 700 at a location uphole of the open lower end 606 of the flow diverter body 602.

In some embodiments, the pump-seating body 700 and the flow diverter body 602 are cooperatively configured such that the reservoir fluid receiver disposed at the distal end 706 of the pump-seating body 700 is disposed downhole of the open lower end 606 of the flow diverter body 602 such that the downhole disposed conductor 202 is releasably coupled to the pump-seating body 700 at a location downhole of the open lower end 606 of the flow diverter body 602.

As described above, in some embodiments, for example, the pump-seating receptacle 702 includes an on/off tool or lugs 703, or any other suitable on/off mechanism known in the art, for releasably coupling the pump 302 or pump assembly to the pump-seating body 700. In the embodiment shown in FIG. 2, by having the pump-seating body 700 effect both the releasable coupling of the pump 302 and the releasable coupling of the downhole disposed conductor 202 within the system 8, the pump 302 may be connected and disconnected from within the pump-seating receptacle 702 of the pump-seating body 700 without having to disconnect from the downhole disposed conductor 202 from the overall assembly 10 which may help to alleviate and/or minimize stresses on the downhole disposed conductor 202 during coupling/de-coupling processes.

In the above description, for purposes of explanation, numerous details are set forth in order to provide a thorough understanding of the present disclosure. However, it will be apparent to one skilled in the art that these specific details are not required in order to practice the present disclosure. Although certain dimensions and materials are described for implementing the disclosed example embodiments, other suitable dimensions and/or materials may be used within the scope of this disclosure. All such modifications and variations, including all suitable current and future changes in technology, are believed to be within the sphere and scope of the present disclosure. All references mentioned are hereby incorporated by reference in their entirety. Therefore, as certain adaptations and modifications of the described embodiments can be made, the above discussed embodiments are considered to be illustrative and not restrictive. 

1.-64. (canceled)
 65. A reservoir fluid conducting system disposed within a wellbore that extends into a subterranean formation and is lined with a wellbore string, wherein the system comprises: a downhole-disposed conductor for receiving the reservoir fluid from a downhole wellbore space; a flow diverter fluidly coupled to the downhole disposed conductor, the flow diverter including a flow diverter body extending between an open lower end and an open upper end and defining an open interior space therebetween; a pump fluidly coupled to the flow diverter body; and a gas-depleted reservoir fluid-producing conductor fluidly coupled to the pump for conducting gas-depleted reservoir fluid, that has been pressurized by the pump, to the surface; wherein: the downhole-disposed conductor, the pump, the flow diverter body, and the gas-depleted reservoir fluid-producing conductor are co-operatively configured such that the flow diverter body defines: a reservoir fluid receiving space disposed within the open interior space of the flow diverter body for receiving reservoir fluid discharged from the downhole disposed conductor; a gas-depleted reservoir fluid receiving space disposed within the open interior space of the flow diverter body uphole of the reservoir fluid receiving space; and a sealed interface fluidly isolating the gas-depleted reservoir fluid receiving space from the reservoir fluid receiving space; and while the downhole-disposed conductor is receiving reservoir fluid from the downhole wellbore space that has been received within the downhole wellbore space from the subterranean formation: the reservoir fluid is conducted uphole to a reservoir fluid separation space via the flow diverter where, within the reservoir fluid separation space, a gas-depleted reservoir fluid is separated from the reservoir fluid, in response to at least buoyancy forces, such that the gas-depleted reservoir fluid is obtained; the gas-depleted reservoir fluid obtained within the reservoir fluid separation space is received by the flow diverter body and conducted to the pump via the gas-depleted reservoir fluid receiving space; and the gas-depleted reservoir fluid is pressurized by the pump and conducted to the surface via the gas-depleted reservoir fluid-producing conductor.
 66. The system as claimed in claim 65, wherein: an intermediate reservoir fluid-conducting passage is disposed between the flow diverter body and the wellbore string; and the downhole-disposed conductor, the intermediate reservoir fluid-conducting passage, and the reservoir fluid separation space are co-operatively configured such that, while the downhole-disposed conductor is receiving reservoir fluid from the downhole wellbore space that has been received within the downhole wellbore space from the subterranean formation: the reservoir fluid that is received by the downhole-disposed conductor and conducted uphole to the reservoir fluid separation space, is conducted uphole via the intermediate reservoir fluid-conducting passage.
 67. The system as claimed in claim 65, further comprising: a pump-seating body is disposed within the open upper end of the flow diverter body, the pump-seating body configured for receiving and releasably-connecting with the pump.
 68. The system as claimed in claim 67, wherein the pump-seating body includes a pump-seating nipple for effecting the releasable connection between the pump and the pump-seating body.
 69. The system as claimed in claim 67, wherein: the flow diverter body defines a gas-depleted reservoir fluid receiver; and the flow diverter body is suspended from the pump-seating body such that a gas-depleted reservoir fluid conducing passage is disposed between the pump-seating body and the flow diverter body extending between and fluidly interconnecting the gas-depleted reservoir fluid receiver and the gas-depleted reservoir fluid receiving space for conducting the gas-depleted reservoir fluid obtained within the reservoir fluid separation space to the gas-depleted reservoir fluid space.
 70. The system as claimed in claim 69, wherein: the suspension of the flow diverter body from the pump-seating body is effected by a hanger assembly, wherein the hanger assembly is configured such that interference with the conducting of the gas-depleted reservoir fluid from the reservoir fluid separation space to the gas-depleted reservoir fluid receiving space via the gas-depleted reservoir fluid conducting passage is prevented, or substantially prevented.
 71. The system as claimed in claim 69, wherein: the pump-seating body defines a pump-intake conducting passage for conducting the gas-depleted reservoir fluid to the pump.
 72. The system as claimed in claim 65, wherein: the flow diverter body defines: a reservoir fluid discharge opening at the open lower end of the flow diverter body; and a reservoir fluid conducting passage disposed between the downhole disposed conductor and the flow diverter body for conducting reservoir fluid from the reservoir fluid receiving space to the reservoir fluid discharge opening.
 73. The system as claimed in claim 65, wherein: the downhole disposed conductor includes a discharge end disposed within the open lower end of the flow diverter body such that there is an absence of support between the downhole disposed conductor and the flow diverter body.
 74. The system as claimed in claim 73, wherein: the downhole disposed conductor and the flow diverter body are cooperatively configured such that the discharge end is disposed within the reservoir fluid-receiving space and is spaced apart from the sealed interface.
 75. The system as claimed in claim 71, wherein: the pump-seating body includes a gas-depleted reservoir fluid inlet disposed uphole of the sealed interface in fluid communication with the gas-depleted reservoir fluid receiving space such that the gas-depleted reservoir fluid is communicated to the pump-intake conducting passage from the gas-depleted reservoir fluid receiving space via the gas-depleted reservoir fluid inlet.
 76. The system as claimed in claim 75, wherein: the gas-depleted reservoir fluid inlet is disposed at a distal end of the pump-seating body; and the pump-seating body and the flow diverter body are cooperatively configured such that the distal end of the pump-seating body disposed within the gas-depleted reservoir fluid receiving space uphole and spaced apart from the sealed interface.
 77. The system as claimed in claim 71, wherein: the pump-seating body includes: a reservoir fluid receiver configured for releasably coupling with the downhole disposed conductor; a gas-depleted reservoir fluid inlet; a reservoir fluid outlet disposed downhole of the gas-depleted reservoir fluid inlet; and a sealed interface disposed intermediate the gas-depleted reservoir fluid inlet and the reservoir fluid outlet such that the reservoir fluid outlet is fluidly isolated from the gas-depleted reservoir fluid inlet; wherein the pump-seating body, the flow diverter body and the downhole disposed conductor are cooperatively configured such that, while the downhole disposed conductor is releasably coupled to the pump-seating body via the reservoir fluid receiver: the reservoir fluid outlet is disposed downhole of the sealed interface of the flow diverter body in fluid communication with the reservoir fluid receiving space; and the gas-depleted reservoir fluid inlet is disposed uphole of the sealed interface of the flow diverter body in fluid communication with the gas-depleted reservoir fluid receiving space; such that, while the downhole-disposed conductor is receiving reservoir fluid from the downhole wellbore space that has been received within the downhole wellbore space from the subterranean formation: the reservoir fluid that is received by the downhole-disposed conductor is communicated to the reservoir fluid receiving space via the reservoir fluid outlet; and the gas-depleted reservoir fluid that is obtained within the reservoir fluid separation space and received within the gas-depleted reservoir fluid receiving space is communicated to the pump-intake conducting passage via the gas-depleted reservoir fluid inlet.
 78. The system as claimed in claim 66, further comprising: a supporting member for supporting the flow diverter body relative to the wellbore string.
 79. The system as claimed in claim 78, wherein: the supporting member is configured such that interference to the conduction of reservoir fluid received within the reservoir fluid receiving space to the reservoir fluid separation space via the intermediate reservoir fluid conducting passage is prevented or substantially prevented.
 80. The system as claimed in claim 65, further comprising: a liquid-depleted gas flow conducting passage for conducting a liquid-depleted gas flow, separated from the reservoir fluid within the reservoir fluid separation space, to the surface.
 81. A reservoir fluid conducting system disposed within a wellbore that extends into a subterranean formation and is lined with a wellbore string that includes a wellbore string-defined flow diverter counterpart, wherein the system comprises: a downhole-disposed conductor for receiving the reservoir fluid from a downhole wellbore space; and a production assembly, suspended within the wellbore, including: an assembly-defined flow diverter counterpart; a pump; and a gas-depleted reservoir fluid-producing conductor for conducting gas-depleted reservoir fluid, that has been pressurized by the pump, to the surface; wherein: the assembly-defined flow diverter counterpart includes a flow diverter body, the flow diverter body extending between an open lower end and an open upper end and defining an open interior space therebetween; and the wellbore string-defined flow diverter counterpart and the assembly-defined flow diverter counterpart are co-operatively configured to define a flow diverter; wherein: the pump is releasably connected to the flow diverter; and the flow diverter body defines a reservoir fluid receiving space disposed within the open interior space of the flow diverter body for receiving reservoir fluid discharged from the downhole disposed conductor, and a gas-depleted reservoir fluid receiving space disposed within the open interior space of the flow diverter body uphole of the reservoir fluid receiving space, the reservoir fluid receiving space and the gas-depleted reservoir fluid receiving space being cooperatively configured such that the reservoir fluid receiving space is fluidly isolated from the gas-depleted reservoir fluid receiving space; and the downhole-disposed conductor, the flow diverter body, the pump, and the gas-depleted reservoir fluid-producing conductor are co-operatively configured such that, while the downhole-disposed conductor is receiving reservoir fluid from the downhole wellbore space that has been received within the downhole wellbore space from the subterranean formation: the reservoir fluid is received within the reservoir fluid receiving space and conducted uphole to a reservoir fluid separation space via the flow diverter; within the reservoir fluid separation space, a gas-depleted reservoir fluid is separated from the reservoir fluid, in response to at least buoyancy forces, such that the gas-depleted reservoir fluid is obtained; the gas-depleted reservoir fluid obtained within the reservoir fluid separation space is received within the flow diverter body and conducted to the pump via the gas-depleted reservoir fluid receiving space; and the gas-depleted reservoir fluid is pressurized by the pump and conducted to the surface via the gas-depleted reservoir fluid-producing conductor.
 82. The system as claimed in claim 81, wherein: the flow diverter body includes a shroud; the wellbore string-defined flow diverter counterpart and the shroud are co-operatively configured such that an intermediate reservoir fluid-conducting passage is disposed between the shroud and the wellbore string-defined flow diverter counterpart; the shroud includes a gas-depleted reservoir fluid conductor for conducting the received gas-depleted reservoir fluid to the pump; and the downhole-disposed conductor, the intermediate reservoir fluid-conducting passage, and the reservoir fluid separation space are co-operatively configured such that, while the downhole-disposed conductor is receiving reservoir fluid from the downhole wellbore space that has been received within the downhole wellbore space from the subterranean formation, and is supplying the received reservoir fluid to an uphole wellbore space: the reservoir fluid, that is discharged into the uphole wellbore space by the downhole-disposed conductor and conducted uphole to the reservoir fluid separation space, is conducted uphole via the intermediate reservoir fluid-conducting passage.
 83. A reservoir fluid production assembly for disposition within a wellbore that extends into a subterranean formation and is lined with a wellbore string, wherein the reservoir fluid production assembly comprises: an assembly-defined flow diverter counterpart; a pump; and a gas-depleted reservoir fluid-producing conductor fluidly coupled to the pump for conducting gas-depleted reservoir fluid, that has been pressurized by the pump, to the surface; wherein the assembly-defined flow diverter counterpart includes: a pump-seating body for receiving and releasably-connecting with the pump; and a flow diverter body extending between an open upper end and an open lower end, the flow diverter body defining: a gas-depleted reservoir fluid receiver disposed at the open upper end of the flow diverter body for receiving gas-depleted reservoir fluid obtained within a reservoir fluid separation space; a gas-depleted reservoir fluid receiving space for receiving gas-depleted reservoir fluid from the gas-depleted reservoir fluid receiver; a reservoir fluid receiving space disposed downhole from the gas-depleted reservoir fluid receiving space for receiving reservoir fluid from the subterranean formation, the reservoir fluid receiving space being fluidly isolated from the gas-depleted reservoir fluid receiving space; and a reservoir fluid discharge opening disposed at the open lower end of the flow diverter body; and a first supporting member for suspending the flow diverter body from the pump seating body; wherein the pump-seating body, the flow diverter body, the pump, the gas-depleted reservoir fluid-producing conductor and the supporting member are co-operatively configured such that: the pump-seating body is disposed within the open upper end of the flow diverter body such that the pump-intake conducting passage is fluidly coupled to the gas-depleted reservoir fluid receiving space for conducting gas-depleted reservoir fluid to the pump for displacement uphole via the gas-depleted reservoir fluid-producing conductor; and the flow diverter body is suspended from the pump-seating body by the supporting member such that a gas-depleted reservoir fluid conducting passage is disposed between the pump-intake conducting passage and the flow diverter body for conducting gas-depleted reservoir fluid received within the gas-depleted reservoir fluid receiver to the gas-depleted reservoir fluid receiving space.
 84. The assembly as claimed in claim 83, wherein: the wellbore includes a downhole disposed conductor configured for receiving reservoir fluid from a downhole wellbore space and conducting the reservoir fluid received from the downhole wellbore space to an uphole wellbore space, the downhole disposed fluid conductor having a discharge end for discharging the reservoir fluid received from the downhole wellbore space to the uphole wellbore space; and disposition of the reservoir fluid production assembly within the wellbore is such that: the discharge end of the downhole disposed fluid conductor is disposed within the open lower end of the flow diverter body such that, while the downhole disposed fluid conductor is receiving reservoir fluid from the downhole wellbore space, reservoir fluid is discharged from the downhole disposed fluid conductor into the reservoir fluid receiving space, the downhole disposed fluid conductor remaining free from connection to the flow diverter body. 